CA2637561C - Apparatus and methods for measuring pressure using a formation tester - Google Patents
Apparatus and methods for measuring pressure using a formation tester Download PDFInfo
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- CA2637561C CA2637561C CA2637561A CA2637561A CA2637561C CA 2637561 C CA2637561 C CA 2637561C CA 2637561 A CA2637561 A CA 2637561A CA 2637561 A CA2637561 A CA 2637561A CA 2637561 C CA2637561 C CA 2637561C
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- 238000000429 assembly Methods 0.000 claims abstract description 48
- 230000004044 response Effects 0.000 claims description 11
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- 238000009530 blood pressure measurement Methods 0.000 abstract description 17
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Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L15/00—Devices or apparatus for measuring two or more fluid pressure values simultaneously
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L19/00—Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
- G01L19/0092—Pressure sensor associated with other sensors, e.g. for measuring acceleration or temperature
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01L—MEASURING FORCE, STRESS, TORQUE, WORK, MECHANICAL POWER, MECHANICAL EFFICIENCY, OR FLUID PRESSURE
- G01L19/00—Details of, or accessories for, apparatus for measuring steady or quasi-steady pressure of a fluent medium insofar as such details or accessories are not special to particular types of pressure gauges
- G01L19/04—Means for compensating for effects of changes of temperature, i.e. other than electric compensation
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- Mining & Mineral Resources (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Fluid Mechanics (AREA)
- Environmental & Geological Engineering (AREA)
- Geophysics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Measuring Fluid Pressure (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
A system for measuring pressure in a well borehole using two pressure sensing gauges that are exposed to an area of common pressure. Pressure measurements are made with preferably two pressure gauge assemblies each containing a single pressure sensing gauge. The two pressure gauge assemblies are removably disposed within a receptacle or "pocket" in the outer surface of a wall of a formation tester tool section. When disposed or "side loaded" in the pocket, the gauges within the pair of assemblies are axially aligned and positioned in a plane that is normal to the radius of the formation tester tool section. Both pressure sensing gauges can be connected to respond to the same fluid pressure originating from a probe or port section of a formation tester tool. By disposing the pressure gauge assemblies in a receptacle or "pocket" in the outer surface or wall of a formation tester tool section, the pressure sensing gauges are exposed to wellbore fluids. Pressure sensing gauges are selected to have low mass. The low mass of the gauges and a cooperating heater assembly allow the pressure gauges to rapidly thermally stabilize with changing temperatures in the wellbore.
Description
2 FORMATION TESTER
3
4 FIELD OF THE INVENTION
This invention is related to borehole formation testing. More 6 particularly, the invention is related to the measure of fluid pressure at one or 7 more locations within the borehole environs using a formation tester tool with 8 dual axially aligned pressure gauges with parallel major axes disposed in one or 9 more pressure gauge assemblies.
12 A variety of systems are used in borehole geophysical exploration 13 and production operations to determine chemical and physical parameters of 14 materials in the borehole environs. The borehole environs include materials, such as fluids or formation matrix, in the vicinity of a borehole as well as 16 materials, such as fluids, within the borehole. The various systems include, but 17 are not limited to, formation testers and borehole fluid analysis systems 18 conveyed within the borehole. In all of these systems, it is preferred to make all 19 measurements in real-time and within instrumentation in the borehole.
However, methods that collect data and fluids for later retrieval and processing are not 21 precluded.
22 Formation tester systems are used in the oil and gas industry 23 primarily to measure pressure and other reservoir parameters of a formation 24 penetrated by a borehole, and to collect and analyze fluids from the borehole environs to determine major constituents within the fluid. Formation testing 26 systems are also used to measure pressure and other parameters of fluid within 1 the borehole. These parametric measurements are typically combined with in 2 situ or uphole analyses of physical and chemical properties of the formation fluid 3 to evaluate production prospects of reservoirs penetrated by the borehole.
By 4 definition, formation fluid refers to any and all fluid including any mixture of fluids.
Regarding formation fluid sampling, it is of prime importance that 6 fluid collected for analysis represents virgin formation fluid with little 7 contamination from fluids used in the borehole drilling operation. Various 8 techniques have been used to minimize sample contamination including the 9 monitoring of fluid pumped through a borehole instrument or borehole "tool"
of the formation tester system until one and/or more fluid properties, such as 11 resistivity, cease to change as a function of time. Other techniques use multiple 12 fluid input ports combined with borehole isolation elements such as packers and 13 pad probes to minimize fluid contamination. Regardless of the fluid sampling 14 methodology, accurate and precise measurements of fluid pressure are required to obtain meaningful reservoir production information.
16 Formation tester tools can be conveyed along the borehole by a 17 variety of means including, but not limited too, a single or multi-conductor 18 wireline, a"slick" line, a drill string, a permanent completion string, or a string of 19 coiled tubing. Formation tester tools may be designed for wireline usage or as part of a drill string. Tool response data and information as well as tool 21 operational data can be transferred to and from the surface of the earth using 22 wireline, coiled tubing and drill string telemetry systems. Altemately, tool 23 response data and information can be stored in memory within the tool for 24 subsequent retrieval at the surface of the earth.
1 Various methods are used to draw fluid into the formation tester 2 tool for pressure measurements, analysis, sampling, and optionally for 3 subsequent exhausting the fluid into the borehole. One method employs a 4 radially extendable sampling pad that is pressed against the wall of the borehole.
A probe port or "snorkel" may or may not be extended from the center of the pad 6 through any borehole mudcake to make contact with formation material. Fluid is 7 drawn into the formation tester tool via a flow line cooperating with the snorkel.
8 Formation pressure is determined from a measure of fluid pressure within the 9 probe flow line. In order to isolate this fluid flow into the probe from fluid flow from the borehole or from the contaminated zone, fluid can be drawn into a 11 guard ring surrounding the snorkel. A more detailed description of the probe and 12 guard ring methodology is presented in U.S. Patent No. 6,301,959 B1. Using a 13 second method, the formation is isolated from the borehole by one or more 14 packers controlled by the packer section of the formation tester tool. A
plurality of packers can be configured axially as "straddle" packers. Fluid is drawn into 16 the formation tester tool via a port flow line cooperating with one or more ports 17 disposed in the wall of the tool between the two straddle packers.
Formation 18 pressure is determined from a measure of fluid pressure within the port flow line.
19 Straddle packers and their use are disclosed in U.S. Patent No. 5,337,821.
2 This disclosure is directed toward a pressure gauge assembly 3 comprising two pressure sensing gauges (or simply "pressure gauges" or 4 "gauges") that are exposed to an area of common pressure. Stated another way, the two pressure gauges are configured to be exposed to and respond 6 simultaneously to the same fluid sample. Preferably a plurality of pressure 7 gauge assemblies is disposed in a formation tester tool to yield fluid pressure 8 measurements at various locations within the borehole environs. As a first 9 example, a pressure gauge assembly can be hydraulically coupled to a probe flow line to measure formation pressure at the probe. As a second example, a 11 pressure gauge assembly can be hydraulically coupled to a port flow line to 12 measure borehole fluid pressure isolated by a straddle packer.
13 Pressure measurements are made with one or more pressure 14 gauge assemblies. A pressure gauge assembly preferably comprises one pressure sensing gauge, and two pressure gauge assemblies are disposed so 16 that pressure gauges are axially aligned and both responsive to a pressure being 17 measured. Aitemately, two pressure gauges can be disposed and axially 18 aligned within a single pressure gauge assembly. Using either assembly 19 embodiment, the gauges are electronically connected to an assembly electrical connector disposed at one end of the pressure gauge assembly. The gauges 21 are hydraulically coupled to assembly hydraulic connectors at the opposite end 22 of the pressure gauge assembly. The assembly hydraulic connectors are 23 inserted in the tool body such that both gauges are exposed to the same 24 hydraulic pressure.
1 The preferably two pressure gauge assemblies are removably 2 disposed within a receptacle or "pocket" in the outer surface of a wall of a 3 formation tester tool section. When disposed or "side loaded" in the pocket, the 4 gauges within the pair of assemblies are axially aligned and positioned in a plane that is normal to the radius of the formation tester tool section.
Furthermore, the 6 assembly electronic connector operationally connects to a tool electrical 7 connector thereby establishing electronic connection between the gauges and 8 an electronic section of the formation tester tool. In addition, the assembly 9 hydraulic connector operationally connects to a pressure flow line in the tool body thereby establishing pressure coupling between the two pressure gauges 11 and a port or probe section of the formation tester tool, or to the one or more 12 flowbusses in the tool. Furthermore, both pressure gauges can be connected to 13 respond to the same fluid pressure originating from the probe or port section.
14 This provides a redundant pressure measurement with advantages to be discussed in subsequent sections of this disclosure.
16 By installing the pressure gauge assembly in a receptacle or 17 "pocket" in the outer surface or wall of a formation tester tool section, the 18 pressure sensing gauges are exposed to wellbore fluids. Pressure gauges are 19 selected to have low mass. The low mass of the gauges and a cooperating heater assembly allow the pressure gauges to rapidly thermally stabilize with 21 changing temperatures in the well borehole. Changing temperatures, both 22 heating and cooling, are encountered as the tool is conveyed up and down the 23 borehole.
24 The axial alignment or "side-by-side" gauge geometry reduces the shut in fluid volumes when compared with an "end-to-end" gauge geometry. In
This invention is related to borehole formation testing. More 6 particularly, the invention is related to the measure of fluid pressure at one or 7 more locations within the borehole environs using a formation tester tool with 8 dual axially aligned pressure gauges with parallel major axes disposed in one or 9 more pressure gauge assemblies.
12 A variety of systems are used in borehole geophysical exploration 13 and production operations to determine chemical and physical parameters of 14 materials in the borehole environs. The borehole environs include materials, such as fluids or formation matrix, in the vicinity of a borehole as well as 16 materials, such as fluids, within the borehole. The various systems include, but 17 are not limited to, formation testers and borehole fluid analysis systems 18 conveyed within the borehole. In all of these systems, it is preferred to make all 19 measurements in real-time and within instrumentation in the borehole.
However, methods that collect data and fluids for later retrieval and processing are not 21 precluded.
22 Formation tester systems are used in the oil and gas industry 23 primarily to measure pressure and other reservoir parameters of a formation 24 penetrated by a borehole, and to collect and analyze fluids from the borehole environs to determine major constituents within the fluid. Formation testing 26 systems are also used to measure pressure and other parameters of fluid within 1 the borehole. These parametric measurements are typically combined with in 2 situ or uphole analyses of physical and chemical properties of the formation fluid 3 to evaluate production prospects of reservoirs penetrated by the borehole.
By 4 definition, formation fluid refers to any and all fluid including any mixture of fluids.
Regarding formation fluid sampling, it is of prime importance that 6 fluid collected for analysis represents virgin formation fluid with little 7 contamination from fluids used in the borehole drilling operation. Various 8 techniques have been used to minimize sample contamination including the 9 monitoring of fluid pumped through a borehole instrument or borehole "tool"
of the formation tester system until one and/or more fluid properties, such as 11 resistivity, cease to change as a function of time. Other techniques use multiple 12 fluid input ports combined with borehole isolation elements such as packers and 13 pad probes to minimize fluid contamination. Regardless of the fluid sampling 14 methodology, accurate and precise measurements of fluid pressure are required to obtain meaningful reservoir production information.
16 Formation tester tools can be conveyed along the borehole by a 17 variety of means including, but not limited too, a single or multi-conductor 18 wireline, a"slick" line, a drill string, a permanent completion string, or a string of 19 coiled tubing. Formation tester tools may be designed for wireline usage or as part of a drill string. Tool response data and information as well as tool 21 operational data can be transferred to and from the surface of the earth using 22 wireline, coiled tubing and drill string telemetry systems. Altemately, tool 23 response data and information can be stored in memory within the tool for 24 subsequent retrieval at the surface of the earth.
1 Various methods are used to draw fluid into the formation tester 2 tool for pressure measurements, analysis, sampling, and optionally for 3 subsequent exhausting the fluid into the borehole. One method employs a 4 radially extendable sampling pad that is pressed against the wall of the borehole.
A probe port or "snorkel" may or may not be extended from the center of the pad 6 through any borehole mudcake to make contact with formation material. Fluid is 7 drawn into the formation tester tool via a flow line cooperating with the snorkel.
8 Formation pressure is determined from a measure of fluid pressure within the 9 probe flow line. In order to isolate this fluid flow into the probe from fluid flow from the borehole or from the contaminated zone, fluid can be drawn into a 11 guard ring surrounding the snorkel. A more detailed description of the probe and 12 guard ring methodology is presented in U.S. Patent No. 6,301,959 B1. Using a 13 second method, the formation is isolated from the borehole by one or more 14 packers controlled by the packer section of the formation tester tool. A
plurality of packers can be configured axially as "straddle" packers. Fluid is drawn into 16 the formation tester tool via a port flow line cooperating with one or more ports 17 disposed in the wall of the tool between the two straddle packers.
Formation 18 pressure is determined from a measure of fluid pressure within the port flow line.
19 Straddle packers and their use are disclosed in U.S. Patent No. 5,337,821.
2 This disclosure is directed toward a pressure gauge assembly 3 comprising two pressure sensing gauges (or simply "pressure gauges" or 4 "gauges") that are exposed to an area of common pressure. Stated another way, the two pressure gauges are configured to be exposed to and respond 6 simultaneously to the same fluid sample. Preferably a plurality of pressure 7 gauge assemblies is disposed in a formation tester tool to yield fluid pressure 8 measurements at various locations within the borehole environs. As a first 9 example, a pressure gauge assembly can be hydraulically coupled to a probe flow line to measure formation pressure at the probe. As a second example, a 11 pressure gauge assembly can be hydraulically coupled to a port flow line to 12 measure borehole fluid pressure isolated by a straddle packer.
13 Pressure measurements are made with one or more pressure 14 gauge assemblies. A pressure gauge assembly preferably comprises one pressure sensing gauge, and two pressure gauge assemblies are disposed so 16 that pressure gauges are axially aligned and both responsive to a pressure being 17 measured. Aitemately, two pressure gauges can be disposed and axially 18 aligned within a single pressure gauge assembly. Using either assembly 19 embodiment, the gauges are electronically connected to an assembly electrical connector disposed at one end of the pressure gauge assembly. The gauges 21 are hydraulically coupled to assembly hydraulic connectors at the opposite end 22 of the pressure gauge assembly. The assembly hydraulic connectors are 23 inserted in the tool body such that both gauges are exposed to the same 24 hydraulic pressure.
1 The preferably two pressure gauge assemblies are removably 2 disposed within a receptacle or "pocket" in the outer surface of a wall of a 3 formation tester tool section. When disposed or "side loaded" in the pocket, the 4 gauges within the pair of assemblies are axially aligned and positioned in a plane that is normal to the radius of the formation tester tool section.
Furthermore, the 6 assembly electronic connector operationally connects to a tool electrical 7 connector thereby establishing electronic connection between the gauges and 8 an electronic section of the formation tester tool. In addition, the assembly 9 hydraulic connector operationally connects to a pressure flow line in the tool body thereby establishing pressure coupling between the two pressure gauges 11 and a port or probe section of the formation tester tool, or to the one or more 12 flowbusses in the tool. Furthermore, both pressure gauges can be connected to 13 respond to the same fluid pressure originating from the probe or port section.
14 This provides a redundant pressure measurement with advantages to be discussed in subsequent sections of this disclosure.
16 By installing the pressure gauge assembly in a receptacle or 17 "pocket" in the outer surface or wall of a formation tester tool section, the 18 pressure sensing gauges are exposed to wellbore fluids. Pressure gauges are 19 selected to have low mass. The low mass of the gauges and a cooperating heater assembly allow the pressure gauges to rapidly thermally stabilize with 21 changing temperatures in the well borehole. Changing temperatures, both 22 heating and cooling, are encountered as the tool is conveyed up and down the 23 borehole.
24 The axial alignment or "side-by-side" gauge geometry reduces the shut in fluid volumes when compared with an "end-to-end" gauge geometry. In
5 1 addition, the shut in fluid volume is equal for both gauges and both gauges are 2 exposed to identical fluid. The axial alignment or side by side geometry has the 3 added benefit of exposing the pressure gauges to the exact same pressure with 4 no change due to the hydrostatic difference that is observed with an axially spaced or "end-to-end" gauge geometry.
6 Within the tool body, hydraulic fluid can be circulated through the
7 heater assembly that contacts the pressure gauge assemblies. The heater
8 assembly disposed in the tool body heats the pressure gauges thereby rapidly
9 raising the temperature of the pressure gauge assemblies. In the embodiment discussed in detail in this disclosure, the heater element is hydraulic but an 11 electric heater element is not precluded. This heater assembly methodology 12 rapidly elevates both gauges to temperatures in a range normally encountered in 13 a borehole environment thereby avoiding excessive time for the pressure gauge 14 assembly to reach thermal equilibrium with the borehole environs. The low mass of the assembly allows rapid response to changes in temperature, both heating 16 and cooling, as the tool is moved up and down the borehole.
17 The dual pressure gauges provide redundant pressure 18 measurements from a common pressure area. A divergence in the two pressure 19 measurements indicates that at least one pressure gauge is malfunctioning.
The pressure response from the working gauge can be used to determine fluid 21 pressure thereby avoiding aborting a formation testing operation.
22 The side loading feature of the pressure gauge assembly allows 23 the assembly to be changed quickly with minimal operation down time. Since 24 assemblies can be easily changed, they can be calibrated off site and inserted into the formation tester tool immediately prior to testing operations.
1 Furthermore, the same pressure gauge assembly can be disposed sequentially 2 in a plurality of tester tools thereby minimizing systematic error in multiple run or 3 multiple well testing operations.
4 The formation tester tool is conveyed within a well borehole by a conveyance apparatus cooperating with a connecting structure. The 6 conveyance apparatus is disposed at the surface of the earth. The connecting 7 structure that operationally connects the formation tester tool to the conveyance 8 apparatus is a tubular or a wireline cable. The connecting structure can serve as 9 a data conduit between the tool and the conveyance apparatus. The conveyance apparatus is operationally connected to surface equipment, which 11 provides a variety of functions including processing tool response data, 12 controlling operation of the tool, recording measurements made by the tool, 13 tracking the position of the tool within the borehole, and the like.
Measurements 14 can be made in real-time and at a plurality of axial positions or "depths"
during a single trip of the tool in the borehole. Furthermore, a plurality of measurements 16 can be made at a single depth during a single trip of the tool in the borehole.
17 The formation tester tool, in the disclosed embodiment, comprises 18 a plurality of operationally connected tool sections such as, but not limited to, a 19 packer section, a probe or port section, a sample carrier section, a pump section, a hydraulics section, an electronics section, and a telemetry section.
Preferably 21 each tool section is controlled locally and can be operated independently of the 22 other sections. Both the local control and the independent operation are 23 accomplished by a section processor disposed within each tool section.
Fluid 24 flows to and from elements within a tool section are preferably controlled by the section processor. At least one fluid flowbus and at least one hydraulic fluid 1 flowbus preferably extend contiguously through the packer, probe or port tool, 2 sample carrier, and pump sections of the tool. Functions of the tool sections will 3 be discussed in detail in subsequent sections of this disclosure.
4 Fluid is preferably drawn into the tool through one or more probe or port sections using one or more pumps. Each tool section can comprise one or 6 more intake or exhaust ports. Each intake port or exhaust can optionally be 7 configured as a probe, guard, or borehole fluid intake port. As discussed above, 8 borehole fluid contamination is minimized using one or more ports cooperating 9 with borehole isolation elements such as a pad type device that is urged against the wall of the formation, or one or more packers.
13 The manner in which the above recited features and advantages, 14 briefly summarized above, are obtained can be understood in detail by reference to the embodiments illustrated in the appended drawings.
16 Fig. 1 illustrates conceptually the major elements of one 17 embodiment of a formation tester system operating in a well borehole;
18 Fig. 2a is a conceptual, exploded perspective view showing a 19 section of the formation tester and dual pressure gauge assemblies that are received by the section;
21 Fig. 2b illustrates a single pressure gauge assembly comprising two 22 axially aligned pressure sensing gauges;
23 Fig. 3a is a top view of elements of two pressure gauge assemblies 24 disposed in a pocket in the outer surface of the wall of a formation tester section;
1 Fig. 3b is a sectional view of the top view shown in Fig. 3a 2 illustrating a heater assembly that is hydraulically or electrically connected;
3 Fig. 4 illustrates conceptually a pressure gauge assembly disposed 4 in a probe tool section; and Fig. 5 illustrates conceptually a pressure gauge assembly disposed 6 in a port tool section.
9 Basic principles of the pressure gauge assembly are disclosed in detail using an exemplary system embodied as a formation tester tool 11 comprising a plurality of formation tester tool sections.
12 The formation tester tool is conveyed within a well borehole by any 13 suitable conveyance apparatus. Fig. 1 illustrates conceptually the major 14 elements of an embodiment of a formation tester system operating in a well borehole 28 that penetrates earth formation 34. The embodiment of Fig. 1 is 16 preferably an exemplary embodiment of a more general downhole formation 17 tester device using pressure measurements at one or more locations in the 18 formation, in the borehole, or even at locations within the formation tester device.
19 The formation tester tool is denoted as a whole by the numeral 10.
The tool 10 comprises a plurality of operationally connected sections including a 21 packer section 11, a probe or port section 12, a sample carrier section 18, a 22 pump section 20, a hydraulics section 24, an electronics section 22, and a 23 downhole telemetry section 25. One or more fluid flowbusses, illustrated 24 conceptually with a broken line 50, extend contiguously through the packer, 1 probe or port tool, sample carrier, and pump sections 11, 12, 18 and 20, 2 respectively.
3 Again referring to Fig. 1, fluid is drawn into the formation tester tool 4 10 through a probe or port tool section 12. The probe or port section can comprise a snorkel and/or one or more intake ports, which are shown in 6 subsequent illustrations. Fluid flow into the probe or port section 12 is illustrated 7 conceptually with the arrows 36. During the borehole drilling operation, the fluid 8 within near borehole formation can be contaminated with drilling fluid typically 9 comprising solids, fluids, and other materials. Drilling fluid contamination of fluid drawn from the formation 34 is typically minimized using one or more probes 11 cooperating with a borehole isolation element such as a pad type device 12 comprising a probe and a guard, as disclosed in previously referenced U.S.
13 Patent No. 6,301,959 B1. One or more probes extend from the pad onto the 14 formation 34. Alternately, the formation can be isolated from the borehole by one or more packers controlled by the packer section 11. A plurality of packers 16 can be configured axially as "straddle" packers. Straddle packers and their use 17 are disclosed in previously referenced U.S. Patent No. 5,337,821.
18 With the sections of the tool 10 configured in Fig. 1, fluid passes 19 from the probe or port section 12 through a fluid flow line to one or more fluid flowbusses 50 under the action of the pump section 20. A pressure gauge 21 assembly can be disposed essentially anywhere along the flow line or one or 22 more fluid flowbusses 50 to obtain pressure measurements, as will be illustrated 23 subsequently with specific examples. The fluid flow line is preferably short, 24 valved, and is attached to the fluid flowbus. The pressure sensing gauges are 1 normally operationally connected to this short flow line, as will be discussed and 2 illustrated subsequently.
3 In addition, fluid samples can be retained within one or more 4 sample containers within the sample carrier section 18 for return to the surface 42 of the earth for additional analysis. The surface 42 is typically the surface of 6 earth formation or the surface of any water covering the earth formation.
7 The hydraulic section 24 depicted in Fig. 1 provides hydraulic 8 power for operating numerous valves and other elements within the tool 10 to 9 control both formation and hydraulic fluid flows. Examples of valving schemes are illustrated in U.S. Patent Application Serial No. 11/626,461 filed on January 11 24, 2007 which is assigned to the assignee of this disclosure.
12 The Electronics section 22 shown in Fig. 1 comprises necessary 13 tool control to operate elements of the tool 10 including one or more pressure 14 gauge assemblies, motor control to operate motor elements in the tool, power supplies for the various section electronic elements of the tool, power 16 electronics, an optional telemetry for communication over a wireline to the 17 surface, an optional memory for data storage downhole, and a processor for 18 control, measurement, and communication to and from the motor control and 19 other tool sections. Preferably the individual tool sections optionally contain electronics (not shown) for section control and measurement.
21 Still referring to Fig. 1, the tool 10 can have an optional additional 22 downhole telemetry section 25 for transmitting various data measured within the 23 tool 10 and for receiving commands from surface 42 of the earth. The downhole 24 telemetry section 26 can also receive commands transmitted from the surface of the earth. The upper end of the tool 10 is terminated by a connector 27. The 1 tool 10 is operationally connected to a conveyance apparatus 30 disposed at the 2 surface 42 by means of a connecting structure 26 that is a tubular or a cable.
3 More specifically, the lower or "borehole" end of the connecting structure 26 is 4 operationally connected to the tool 10 through the connector 24. The upper or "surface" end of the connecting structure 26 is operationally connected to the 6 conveyance apparatus 30. The connecting structure 26 can function as a data 7 conduit between the tool 10 and equipment disposed at the surface 42. If the 8 tool 10 is a logging tool element of a wireline formation tester system, the 9 connecting structure 26 represents a preferably multi-conductor wireline logging cable and the conveyance apparatus 30 is a wireline draw works assembly 11 comprising a winch. If the tool 10 is a component of a measurement-while-12 drilling or logging-while-drilling system, the connecting structure 26 is a drill 13 string and the conveyance apparatus 30 is a rotary drilling rig. If the tool 10 is an 14 element of a coiled tubing logging system, the connecting structure 26 is coiled tubing and the conveyance apparatus 30 is a coiled tubing injector. If the tool 10 16 is an element of a drill string tester system, the connecting structure 26 is again 17 a drill string and the conveyance apparatus 30 is again a rotary drilling rig.
18 Again referring to Fig. 1, surface equipment 32 is operationally 19 connected to the tool 10 through the conveyance apparatus 30 and the connecting structure 26. The surface equipment 32 comprises a surface 21 telemetry element (not shown), which communicates with the downhole 22 telemetry section 25. The connecting structure 26 functions as a data conduit 23 between the downhole and surface telemetry elements. The surface unit 32 24 preferably comprises a surface processor that optionally performs additional processing of data measured by sensors and gauges in the tool 10. The surface 1 processor also cooperates with a depth measure device (not shown) to track 2 data measured by the tool 10 as a function of depth within the borehole at which 3 it is measured. The surface equipment 32 preferably comprises recording 4 means for recording "logs" of one or more parameters of interest as a function of time and/or depth.
6 It is noted that Fig. 1 illustrates one embodiment of the formation 7 tester tool 10, and this embodiment is used to disclose basic concepts of the 8 pressure gauge assemblies used in the system. It should be understood, 9 however, that the various sections can be arranged in different axial configurations, and multiple sections of the same type can be added or removed 11 as required for specific borehole operations.
12 Fig. 2a is a conceptual, exploded perspective view showing a 13 pressure measurement system disposed in a section 10a of the formation tester 14 10. The pressure measurement system comprises two pressure gauge assemblies 70a and 70b that are removably disposed within a receptacle or 16 "pocket" 62 in the outer surface of the formation tester section 10a. The tool 17 section 10a can represent any or all of the tool sections 11, 12, 18 20 and 18 discussed previously and illustrated conceptually in Fig. 1.
19 The pressure gauge assemblies 70a and 70b each comprise a pressure sensing gauges 82 and 84, respectively. The assemblies 70a and 70b 21 and the pressure gauges therein are axially aligned "side-by-side" along the 22 major axis of the tool section 10a. The types of pressure sensing gauges 82 and 23 84 may be of any type, such as but are not limited to, strain, quartz, sapphire, or 24 any combination of the different types of pressure gauges. The gauges 82 and 84 are electrically connected to assembly electrical connectors 78a and 78b, 1 respectfully, disposed at one end of the pressure gauge assemblies 70a and 2 70b. The gauges 82 and 84 are hydraulically coupled to assembly hydraulic 3 connectors 74a and 74b, respectively, at the opposite end of the pressure gauge 4 assemblies 70a and 70b. The assembly hydraulic connectors 74a and 74b are configured so that both gauges 82 and 84 are connected in the tool body to the 6 same pressure flow line.
7 Again referring to Fig. 2a, the pressure gauge assemblies 70a and 8 70b are removably disposed within the receptacle or "pocket" 62 in the outer 9 surface of the formation tester tool section 10a. When disposed or "side loaded"
in the pocket 62, the axially aligned gauges 82 and 84 are positioned in a plane 11 that is essentially normal to the radius of the formation tester tool section 10a.
12 The electrical connectors 78a and 78b connect to a tool electrical connector 68 13 thereby establishing electrical connection between the gauges 82 and 84 and an 14 electronic section 22 of the formation tester tool 10 (see Fig. 1). In addition, the assembly hydraulic connectors 74a and 78b operationally connect to a tool 16 hydraulic connector 64 thereby establishing pressure connection, via the one or 17 more fluid flow lines (see Figs 4 and 5), between the gauges 82 and 84 and a 18 port or probe section 12 of the formation tester tool 10 (see Fig. 1), or to one or 19 more fluid flowbusses 50. One or more fluid flow ports, as illustrated at 79 for the section 10a, align with matching ports in additional sections of the tool
17 The dual pressure gauges provide redundant pressure 18 measurements from a common pressure area. A divergence in the two pressure 19 measurements indicates that at least one pressure gauge is malfunctioning.
The pressure response from the working gauge can be used to determine fluid 21 pressure thereby avoiding aborting a formation testing operation.
22 The side loading feature of the pressure gauge assembly allows 23 the assembly to be changed quickly with minimal operation down time. Since 24 assemblies can be easily changed, they can be calibrated off site and inserted into the formation tester tool immediately prior to testing operations.
1 Furthermore, the same pressure gauge assembly can be disposed sequentially 2 in a plurality of tester tools thereby minimizing systematic error in multiple run or 3 multiple well testing operations.
4 The formation tester tool is conveyed within a well borehole by a conveyance apparatus cooperating with a connecting structure. The 6 conveyance apparatus is disposed at the surface of the earth. The connecting 7 structure that operationally connects the formation tester tool to the conveyance 8 apparatus is a tubular or a wireline cable. The connecting structure can serve as 9 a data conduit between the tool and the conveyance apparatus. The conveyance apparatus is operationally connected to surface equipment, which 11 provides a variety of functions including processing tool response data, 12 controlling operation of the tool, recording measurements made by the tool, 13 tracking the position of the tool within the borehole, and the like.
Measurements 14 can be made in real-time and at a plurality of axial positions or "depths"
during a single trip of the tool in the borehole. Furthermore, a plurality of measurements 16 can be made at a single depth during a single trip of the tool in the borehole.
17 The formation tester tool, in the disclosed embodiment, comprises 18 a plurality of operationally connected tool sections such as, but not limited to, a 19 packer section, a probe or port section, a sample carrier section, a pump section, a hydraulics section, an electronics section, and a telemetry section.
Preferably 21 each tool section is controlled locally and can be operated independently of the 22 other sections. Both the local control and the independent operation are 23 accomplished by a section processor disposed within each tool section.
Fluid 24 flows to and from elements within a tool section are preferably controlled by the section processor. At least one fluid flowbus and at least one hydraulic fluid 1 flowbus preferably extend contiguously through the packer, probe or port tool, 2 sample carrier, and pump sections of the tool. Functions of the tool sections will 3 be discussed in detail in subsequent sections of this disclosure.
4 Fluid is preferably drawn into the tool through one or more probe or port sections using one or more pumps. Each tool section can comprise one or 6 more intake or exhaust ports. Each intake port or exhaust can optionally be 7 configured as a probe, guard, or borehole fluid intake port. As discussed above, 8 borehole fluid contamination is minimized using one or more ports cooperating 9 with borehole isolation elements such as a pad type device that is urged against the wall of the formation, or one or more packers.
13 The manner in which the above recited features and advantages, 14 briefly summarized above, are obtained can be understood in detail by reference to the embodiments illustrated in the appended drawings.
16 Fig. 1 illustrates conceptually the major elements of one 17 embodiment of a formation tester system operating in a well borehole;
18 Fig. 2a is a conceptual, exploded perspective view showing a 19 section of the formation tester and dual pressure gauge assemblies that are received by the section;
21 Fig. 2b illustrates a single pressure gauge assembly comprising two 22 axially aligned pressure sensing gauges;
23 Fig. 3a is a top view of elements of two pressure gauge assemblies 24 disposed in a pocket in the outer surface of the wall of a formation tester section;
1 Fig. 3b is a sectional view of the top view shown in Fig. 3a 2 illustrating a heater assembly that is hydraulically or electrically connected;
3 Fig. 4 illustrates conceptually a pressure gauge assembly disposed 4 in a probe tool section; and Fig. 5 illustrates conceptually a pressure gauge assembly disposed 6 in a port tool section.
9 Basic principles of the pressure gauge assembly are disclosed in detail using an exemplary system embodied as a formation tester tool 11 comprising a plurality of formation tester tool sections.
12 The formation tester tool is conveyed within a well borehole by any 13 suitable conveyance apparatus. Fig. 1 illustrates conceptually the major 14 elements of an embodiment of a formation tester system operating in a well borehole 28 that penetrates earth formation 34. The embodiment of Fig. 1 is 16 preferably an exemplary embodiment of a more general downhole formation 17 tester device using pressure measurements at one or more locations in the 18 formation, in the borehole, or even at locations within the formation tester device.
19 The formation tester tool is denoted as a whole by the numeral 10.
The tool 10 comprises a plurality of operationally connected sections including a 21 packer section 11, a probe or port section 12, a sample carrier section 18, a 22 pump section 20, a hydraulics section 24, an electronics section 22, and a 23 downhole telemetry section 25. One or more fluid flowbusses, illustrated 24 conceptually with a broken line 50, extend contiguously through the packer, 1 probe or port tool, sample carrier, and pump sections 11, 12, 18 and 20, 2 respectively.
3 Again referring to Fig. 1, fluid is drawn into the formation tester tool 4 10 through a probe or port tool section 12. The probe or port section can comprise a snorkel and/or one or more intake ports, which are shown in 6 subsequent illustrations. Fluid flow into the probe or port section 12 is illustrated 7 conceptually with the arrows 36. During the borehole drilling operation, the fluid 8 within near borehole formation can be contaminated with drilling fluid typically 9 comprising solids, fluids, and other materials. Drilling fluid contamination of fluid drawn from the formation 34 is typically minimized using one or more probes 11 cooperating with a borehole isolation element such as a pad type device 12 comprising a probe and a guard, as disclosed in previously referenced U.S.
13 Patent No. 6,301,959 B1. One or more probes extend from the pad onto the 14 formation 34. Alternately, the formation can be isolated from the borehole by one or more packers controlled by the packer section 11. A plurality of packers 16 can be configured axially as "straddle" packers. Straddle packers and their use 17 are disclosed in previously referenced U.S. Patent No. 5,337,821.
18 With the sections of the tool 10 configured in Fig. 1, fluid passes 19 from the probe or port section 12 through a fluid flow line to one or more fluid flowbusses 50 under the action of the pump section 20. A pressure gauge 21 assembly can be disposed essentially anywhere along the flow line or one or 22 more fluid flowbusses 50 to obtain pressure measurements, as will be illustrated 23 subsequently with specific examples. The fluid flow line is preferably short, 24 valved, and is attached to the fluid flowbus. The pressure sensing gauges are 1 normally operationally connected to this short flow line, as will be discussed and 2 illustrated subsequently.
3 In addition, fluid samples can be retained within one or more 4 sample containers within the sample carrier section 18 for return to the surface 42 of the earth for additional analysis. The surface 42 is typically the surface of 6 earth formation or the surface of any water covering the earth formation.
7 The hydraulic section 24 depicted in Fig. 1 provides hydraulic 8 power for operating numerous valves and other elements within the tool 10 to 9 control both formation and hydraulic fluid flows. Examples of valving schemes are illustrated in U.S. Patent Application Serial No. 11/626,461 filed on January 11 24, 2007 which is assigned to the assignee of this disclosure.
12 The Electronics section 22 shown in Fig. 1 comprises necessary 13 tool control to operate elements of the tool 10 including one or more pressure 14 gauge assemblies, motor control to operate motor elements in the tool, power supplies for the various section electronic elements of the tool, power 16 electronics, an optional telemetry for communication over a wireline to the 17 surface, an optional memory for data storage downhole, and a processor for 18 control, measurement, and communication to and from the motor control and 19 other tool sections. Preferably the individual tool sections optionally contain electronics (not shown) for section control and measurement.
21 Still referring to Fig. 1, the tool 10 can have an optional additional 22 downhole telemetry section 25 for transmitting various data measured within the 23 tool 10 and for receiving commands from surface 42 of the earth. The downhole 24 telemetry section 26 can also receive commands transmitted from the surface of the earth. The upper end of the tool 10 is terminated by a connector 27. The 1 tool 10 is operationally connected to a conveyance apparatus 30 disposed at the 2 surface 42 by means of a connecting structure 26 that is a tubular or a cable.
3 More specifically, the lower or "borehole" end of the connecting structure 26 is 4 operationally connected to the tool 10 through the connector 24. The upper or "surface" end of the connecting structure 26 is operationally connected to the 6 conveyance apparatus 30. The connecting structure 26 can function as a data 7 conduit between the tool 10 and equipment disposed at the surface 42. If the 8 tool 10 is a logging tool element of a wireline formation tester system, the 9 connecting structure 26 represents a preferably multi-conductor wireline logging cable and the conveyance apparatus 30 is a wireline draw works assembly 11 comprising a winch. If the tool 10 is a component of a measurement-while-12 drilling or logging-while-drilling system, the connecting structure 26 is a drill 13 string and the conveyance apparatus 30 is a rotary drilling rig. If the tool 10 is an 14 element of a coiled tubing logging system, the connecting structure 26 is coiled tubing and the conveyance apparatus 30 is a coiled tubing injector. If the tool 10 16 is an element of a drill string tester system, the connecting structure 26 is again 17 a drill string and the conveyance apparatus 30 is again a rotary drilling rig.
18 Again referring to Fig. 1, surface equipment 32 is operationally 19 connected to the tool 10 through the conveyance apparatus 30 and the connecting structure 26. The surface equipment 32 comprises a surface 21 telemetry element (not shown), which communicates with the downhole 22 telemetry section 25. The connecting structure 26 functions as a data conduit 23 between the downhole and surface telemetry elements. The surface unit 32 24 preferably comprises a surface processor that optionally performs additional processing of data measured by sensors and gauges in the tool 10. The surface 1 processor also cooperates with a depth measure device (not shown) to track 2 data measured by the tool 10 as a function of depth within the borehole at which 3 it is measured. The surface equipment 32 preferably comprises recording 4 means for recording "logs" of one or more parameters of interest as a function of time and/or depth.
6 It is noted that Fig. 1 illustrates one embodiment of the formation 7 tester tool 10, and this embodiment is used to disclose basic concepts of the 8 pressure gauge assemblies used in the system. It should be understood, 9 however, that the various sections can be arranged in different axial configurations, and multiple sections of the same type can be added or removed 11 as required for specific borehole operations.
12 Fig. 2a is a conceptual, exploded perspective view showing a 13 pressure measurement system disposed in a section 10a of the formation tester 14 10. The pressure measurement system comprises two pressure gauge assemblies 70a and 70b that are removably disposed within a receptacle or 16 "pocket" 62 in the outer surface of the formation tester section 10a. The tool 17 section 10a can represent any or all of the tool sections 11, 12, 18 20 and 18 discussed previously and illustrated conceptually in Fig. 1.
19 The pressure gauge assemblies 70a and 70b each comprise a pressure sensing gauges 82 and 84, respectively. The assemblies 70a and 70b 21 and the pressure gauges therein are axially aligned "side-by-side" along the 22 major axis of the tool section 10a. The types of pressure sensing gauges 82 and 23 84 may be of any type, such as but are not limited to, strain, quartz, sapphire, or 24 any combination of the different types of pressure gauges. The gauges 82 and 84 are electrically connected to assembly electrical connectors 78a and 78b, 1 respectfully, disposed at one end of the pressure gauge assemblies 70a and 2 70b. The gauges 82 and 84 are hydraulically coupled to assembly hydraulic 3 connectors 74a and 74b, respectively, at the opposite end of the pressure gauge 4 assemblies 70a and 70b. The assembly hydraulic connectors 74a and 74b are configured so that both gauges 82 and 84 are connected in the tool body to the 6 same pressure flow line.
7 Again referring to Fig. 2a, the pressure gauge assemblies 70a and 8 70b are removably disposed within the receptacle or "pocket" 62 in the outer 9 surface of the formation tester tool section 10a. When disposed or "side loaded"
in the pocket 62, the axially aligned gauges 82 and 84 are positioned in a plane 11 that is essentially normal to the radius of the formation tester tool section 10a.
12 The electrical connectors 78a and 78b connect to a tool electrical connector 68 13 thereby establishing electrical connection between the gauges 82 and 84 and an 14 electronic section 22 of the formation tester tool 10 (see Fig. 1). In addition, the assembly hydraulic connectors 74a and 78b operationally connect to a tool 16 hydraulic connector 64 thereby establishing pressure connection, via the one or 17 more fluid flow lines (see Figs 4 and 5), between the gauges 82 and 84 and a 18 port or probe section 12 of the formation tester tool 10 (see Fig. 1), or to one or 19 more fluid flowbusses 50. One or more fluid flow ports, as illustrated at 79 for the section 10a, align with matching ports in additional sections of the tool
10 21 thereby establishing one (or more) contiguous fluid flowbus conduits illustrated 22 conceptually in Fig.1 by the broken line 50. As stated previously, both gauges 23 82 and 84 are exposed to an area of common pressure, such as fluid pressure 24 originating from the probe or port section 12, thereby providing redundant pressure measurements.
1 The low mass of the pressure sensing gauges 82 and 84 and the 2 cooperating heat exchange assembly 66 (see Figs 3 and 4) allow the pressure 3 gauges to respond rapidly to changing temperatures. The rapid temperature 4 stabilization of the pressure gauge with the well bore temperature reduces operational rig time and ensures accurate pressure readings. Temperature 6 stabilization of the gauges is critical because all pressure sensing gauges are 7 affected by both temperature and pressure simultaneously. Changing pressure 8 gauge temperature causes unstable pressure measurements.
9 The axial alignment or "side-by-side" gauge geometry as illustrated in Figs 2a, 2b and 3 reduces the shut in fluid volumes when compared with an
1 The low mass of the pressure sensing gauges 82 and 84 and the 2 cooperating heat exchange assembly 66 (see Figs 3 and 4) allow the pressure 3 gauges to respond rapidly to changing temperatures. The rapid temperature 4 stabilization of the pressure gauge with the well bore temperature reduces operational rig time and ensures accurate pressure readings. Temperature 6 stabilization of the gauges is critical because all pressure sensing gauges are 7 affected by both temperature and pressure simultaneously. Changing pressure 8 gauge temperature causes unstable pressure measurements.
9 The axial alignment or "side-by-side" gauge geometry as illustrated in Figs 2a, 2b and 3 reduces the shut in fluid volumes when compared with an
11 "end-to-end" gauge geometry. As an example, the shut in fluid volume for the
12 side-by-side gauge geometry would be less than one half the corresponding shut
13 in volume that would typically be required for dual "end-to-end" gauge
14 geometries. In addition, the shut in fluid volume is equal for both gauges.
In pressure transient analysis (PTA), storage volumes play a large role in the 16 interpretation. The much smaller and equal storage volumes have a large 17 benefit during PTA. In an "end-to-end" gauge geometry both gauges are 18 exposed to different pressures due to the gravity head and fluid type in the flow 19 line. The "side-by-side" geometry exposes both pressure gauges to the exact same pressure negating the requirement to make an adjustment between the 21 gauges that is required in the "end-to-end" geometry. This is especially 22 important as the fluid type required for the correction is not always known.
23 Referring to Figs. 3a and 3b along with Fig. 2a, a heater assembly 24 66 connects to the hydraulic section 24 of the formation tester tool 10 (see Fig.
1). Hydraulic fluid circulates through the heater assembly 66 from the tool 1 hydraulics 24 through the hydraulic flowbusses shown conceptually as a broken 2 line 52 in Fig. 1. One or more fluid flow ports as illustrated at 75 and 77 for the 3 section 10a align with matching ports in additional sections of the tool 10 thereby 4 establishing one or more contiguous hydraulic flowbus conduits illustrated conceptually at 52. The heater assembly 66 disposed in the tool body heats the 6 pressure sensing gauges 82 and 84 thereby rapidly raising the temperature of 7 the pressure gauges. In the embodiment shown, the heater assembly 66 is 8 hydraulic but an electric heater element is not precluded. This methodology 9 rapidly elevates both gauges 82 and 84 to temperatures in a range normally encountered in a borehole environment thereby reducing the time for the 11 pressure gauges to reach thermal equilibrium with the borehole environs. In 12 another embodiment (not shown) the heater assembly can be powered 13 electrically.
14 Altemately, two pressure sensing gauges 82 and 84 can be disposed and axially aligned within a single pressure gauge assembly, as 16 depicted in Fig. 2b and denoted at 70. In this embodiment, the gauges 82 and 17 84 are electrically connected to a single assembly electrical connector 78 18 disposed at one end of the pressure gauge assembly 70. The gauges 82 and 84 19 are hydraulically coupled to a single assembly hydraulic connector 74 at the opposite end of the pressure gauge assemblies 70. Again, the assembly 21 hydraulic connector 74 is configured so that both gauges 82 and 84 are 22 connected in the tool body to the same pressure flow line.
23 Fig. 3a is a top view of elements of pressure gauge assemblies 24 70a and 70b disposed in a pocket 62 (see Fig. 2a) and operationally connected 1 to tool hydraulic and electrical connectors 64 and 66, respectively. The gauges 2 82 and 84 are thermally coupled to the heater assembly 66.
3 Fig. 3b is a side sectional view A-A of the top view shown in Fig.
4 3a. This sectional view shows a heater orifice 85 in the heater assembly 66 through which hydraulic fluid is circulated. Circulating hydraulic fluid enters and 6 exits the heater assembly 66 through the flow lines 75 and 77. The heater 7 assembly 66 thermally contacts the gauges 82 and 84 to provide heating to 8 wellbore temperature. This methodology rapidly raises the temperature of the 9 gauges 82 and 84. More specifically, this methodology rapidly elevates both gauges 82 and 84 to temperatures in a range normally encountered in a 11 borehole environment thereby avoiding excessive time for the pressure gauge 12 assemblies 70a and 70b to reach thermal equilibrium with the borehole environs.
13 Once again, the low masses of the gauges 82 and 84 allow the pressure gauges 14 82 and 84 to respond to rapid changes on temperatures. In another embodiment (not shown), orifice 85 shown in Fig. 3b would represent conceptually a heater 16 element in an electric heater assembly.
17 Still referring to Fig. 3b, a fluid flow line 79 is shown connecting the 18 tool hydraulic connector 64 which, through the porting in the tool body, exposes 19 both gauges 82 and 84 to the exact same fluid pressure. It should be noted that during a fluid pressure measurement, the pressure gauge assemblies 70a and 21 70b are isolated from the contiguous fluid flow bus 50 shown in Fig. 1 using 22 valving arrangements of the type illustrated in previously referenced U.S.
Patent 23 Application Serial No. 11/626,461.
24 As mentioned previously, a pressure gauge assembly can be disposed at a variety of positions in a variety of formation tester tool sections to 1 yield redundant pressure measurements. Fig. 4 illustrates conceptually a probe 2 tool section 10a comprising an extendable pad 90 and a protruding probe that 3 penetrates formation material. The probe 92 is hydraulically coupled to both 4 pressure gauge assemblies 70a and 70b via the tool hydraulic connector 64 a fluid flow line 79a. Elements are configured to minimize the length of the flow 6 line 79a. The view depicted in Fig. 4 is from the opposite side of the view shown 7 in Fig. 3b, therefore the pressure gauge assembly 70b is shown. As in 8 previously discussed embodiments, electrical connection is provided to the 9 pressure gauge assembly 70b (and also pressure gauge assembly 70a which is not shown) through the tool electrical connector 68. Electrical connector 68 is, in 11 turn, is electrically connected preferably to the electronics present in each tool 12 section.
13 Fig. 5 illustrates conceptually a probe tool section 10a comprising a 14 port 94 that is in hydraulic communication with fluid in the borehole. This borehole fluid can be isolated by one or more packers such as a straddle packer 16 (not shown) controlled by the packer section 11 of the formation tester tool 10.
17 The port 94 is hydraulically coupled to the pressure gauge assemblies 70a and 18 70b (only assembly 70b is shown) again via the tool hydraulic connector 64 and 19 a fluid flow line 79b. Once again, elements are configured to minimize the length of the flow line 79b. Furthermore, electrical connection is again provided to the 21 pressure gauge assemblies 70a and 70b through the tool electrical connector 22 which, in turn, is electrically connected preferably to the electronics in each tool 23 section. It should be noted that. by using packers as an isolation means, 24 borehole fluid pressure measurements can be made in cased as well as uncased or "open" boreholes.
1 The gauges 82 and 84 are preferably calibrated by exposing the 2 pressure gauge assembly 70a, 70b or 70 to a known pressure at a known 3 ambient temperature as is normal in the industry.
4 The dual pressure gauges 82 and 84 provide redundant fluid pressure measurements at an area of common pressure in the borehole 6 environs. Any divergence in the two pressure measurements indicates that at 7 least one pressure gauge is malfunctioning. The response from the working 8 pressure gauge can be used to determine fluid pressure thereby avoiding 9 aborting the formation testing operation.
As discussed previously, the each pressure gauge assembly 70a, 11 70b or 70 is removably disposed in a recession or pocket 62 on the outer surface 12 of the tool section 10a (see Fig. 2a). This side loading feature allows one or 13 more assemblies to be rapidly changed. Due to the fragile nature of high 14 resolution pressure sensing gauges, the gauges can be transported separately in special handling containers and inserted into the formation tester tool 10 16 immediately prior to testing operations. This is possible as the pressure gauge 17 assemblies 70a, 70b or 70 are accessed from the outer surface of the tool 18 section 10a and can be easily removed and inserted. In addition, the same 19 pressure gauge assemblies 70a, 70b or 70 can be removably disposed sequentially in a plurality of tester tools 10 or tool sections 10a thereby 21 minimizing systematic gauge error in multiple runs or runs in multiple wells. .
22 This is especially important within a single well or for a field study of multiple 23 wells.
24 Pressure values are obtained for the numerous circumstances and conditions discussed above by combining responses of the pressure gauges 1 using a processor and preferably the processor disposed in the previously 2 discussed electronics section 22 (see Fig. 1).
Preferably two pressure gauge assemblies are used to provide 6 redundant pressure measurements at a given location of the borehole environs.
7 If the preferred two pressure gauge assemblies are used, each assembly 8 comprises a pressure sensing gauge. The pressure gauge assemblies are 9 disposed such that the pressure gauges are axially aligned with parallel major axes. If one pressure gauge assembly is used, two pressure gauges are axially 11 aligned within the assembly. Pressure gauge assemblies are removably 12 disposed within a receptacle or "pocket" in the outer surface of a formation tester 13 tool or formation tester tool section. When disposed or "side loaded" in the 14 pocket, the assembly's axially aligned gauges are positioned in a plane that is essentially normal to the radius of the formation tester tool. The axial alignment 16 or "side-by-side" geometry reduces and equalizes fluid flow line volumes 17 between the gauges as well as eliminating errors between the pressure gauges 18 due to hydrostatic head. Both the volumes are equal and the fluids are 19 identically the same for both gauges. This is important because the fluid properties such as compressibility and viscosity will be the same for these same 21 fluids of equal volume. This, in turn, is important during pressure transient 22 testing when fluid properties such as compressibility effects must be taken into 23 consideration. This is also important when doing pressure, volume, temperature 24 (PVT) testing. All of these features are not possible using axially spaced or "end-to-end" gauge geometry. The exposed geometry of the pressure gauge 1 assemblies allows quick stabilization to wellbore temperature. As well, the 2 exposed geometry in combination with the low mass of the gauges and the 3 cooperating heater assembly allow the pressure gauges to respond to rapid 4 wellbore temperatures changes that are encountered as the tool is moved up and down the well borehole. In addition, the heater assembly can assist raising 6 the pressure gauge temperature to the wellbore temperature rapidly.
7 Any divergence in pressure measurements between the dual 8 gauges indicates that at least one pressure gauge is malfunctioning. The 9 response of the working gauge can be used to determine fluid pressure thereby avoiding aborting the formation testing operation. The axial alignment or "side-11 by-side" gauge geometry reduces shut in fluid volumes when compared with an 12 "end-to-end" or axially spaced gauge geometry. The side loading feature of the 13 pressure gauge assembly allows the assembly to be changed with minimal 14 operation down time. Furthermore, the same pressure gauge assembly can be disposed sequentially in a plurality of tester tools thereby minimizing systematic 16 error in multiple run or multiple well testing operations.
17 While the foregoing disclosure is directed toward the preferred 18 embodiments of the invention, the scope of the invention is defined by the 19 claims, which follow.
In pressure transient analysis (PTA), storage volumes play a large role in the 16 interpretation. The much smaller and equal storage volumes have a large 17 benefit during PTA. In an "end-to-end" gauge geometry both gauges are 18 exposed to different pressures due to the gravity head and fluid type in the flow 19 line. The "side-by-side" geometry exposes both pressure gauges to the exact same pressure negating the requirement to make an adjustment between the 21 gauges that is required in the "end-to-end" geometry. This is especially 22 important as the fluid type required for the correction is not always known.
23 Referring to Figs. 3a and 3b along with Fig. 2a, a heater assembly 24 66 connects to the hydraulic section 24 of the formation tester tool 10 (see Fig.
1). Hydraulic fluid circulates through the heater assembly 66 from the tool 1 hydraulics 24 through the hydraulic flowbusses shown conceptually as a broken 2 line 52 in Fig. 1. One or more fluid flow ports as illustrated at 75 and 77 for the 3 section 10a align with matching ports in additional sections of the tool 10 thereby 4 establishing one or more contiguous hydraulic flowbus conduits illustrated conceptually at 52. The heater assembly 66 disposed in the tool body heats the 6 pressure sensing gauges 82 and 84 thereby rapidly raising the temperature of 7 the pressure gauges. In the embodiment shown, the heater assembly 66 is 8 hydraulic but an electric heater element is not precluded. This methodology 9 rapidly elevates both gauges 82 and 84 to temperatures in a range normally encountered in a borehole environment thereby reducing the time for the 11 pressure gauges to reach thermal equilibrium with the borehole environs. In 12 another embodiment (not shown) the heater assembly can be powered 13 electrically.
14 Altemately, two pressure sensing gauges 82 and 84 can be disposed and axially aligned within a single pressure gauge assembly, as 16 depicted in Fig. 2b and denoted at 70. In this embodiment, the gauges 82 and 17 84 are electrically connected to a single assembly electrical connector 78 18 disposed at one end of the pressure gauge assembly 70. The gauges 82 and 84 19 are hydraulically coupled to a single assembly hydraulic connector 74 at the opposite end of the pressure gauge assemblies 70. Again, the assembly 21 hydraulic connector 74 is configured so that both gauges 82 and 84 are 22 connected in the tool body to the same pressure flow line.
23 Fig. 3a is a top view of elements of pressure gauge assemblies 24 70a and 70b disposed in a pocket 62 (see Fig. 2a) and operationally connected 1 to tool hydraulic and electrical connectors 64 and 66, respectively. The gauges 2 82 and 84 are thermally coupled to the heater assembly 66.
3 Fig. 3b is a side sectional view A-A of the top view shown in Fig.
4 3a. This sectional view shows a heater orifice 85 in the heater assembly 66 through which hydraulic fluid is circulated. Circulating hydraulic fluid enters and 6 exits the heater assembly 66 through the flow lines 75 and 77. The heater 7 assembly 66 thermally contacts the gauges 82 and 84 to provide heating to 8 wellbore temperature. This methodology rapidly raises the temperature of the 9 gauges 82 and 84. More specifically, this methodology rapidly elevates both gauges 82 and 84 to temperatures in a range normally encountered in a 11 borehole environment thereby avoiding excessive time for the pressure gauge 12 assemblies 70a and 70b to reach thermal equilibrium with the borehole environs.
13 Once again, the low masses of the gauges 82 and 84 allow the pressure gauges 14 82 and 84 to respond to rapid changes on temperatures. In another embodiment (not shown), orifice 85 shown in Fig. 3b would represent conceptually a heater 16 element in an electric heater assembly.
17 Still referring to Fig. 3b, a fluid flow line 79 is shown connecting the 18 tool hydraulic connector 64 which, through the porting in the tool body, exposes 19 both gauges 82 and 84 to the exact same fluid pressure. It should be noted that during a fluid pressure measurement, the pressure gauge assemblies 70a and 21 70b are isolated from the contiguous fluid flow bus 50 shown in Fig. 1 using 22 valving arrangements of the type illustrated in previously referenced U.S.
Patent 23 Application Serial No. 11/626,461.
24 As mentioned previously, a pressure gauge assembly can be disposed at a variety of positions in a variety of formation tester tool sections to 1 yield redundant pressure measurements. Fig. 4 illustrates conceptually a probe 2 tool section 10a comprising an extendable pad 90 and a protruding probe that 3 penetrates formation material. The probe 92 is hydraulically coupled to both 4 pressure gauge assemblies 70a and 70b via the tool hydraulic connector 64 a fluid flow line 79a. Elements are configured to minimize the length of the flow 6 line 79a. The view depicted in Fig. 4 is from the opposite side of the view shown 7 in Fig. 3b, therefore the pressure gauge assembly 70b is shown. As in 8 previously discussed embodiments, electrical connection is provided to the 9 pressure gauge assembly 70b (and also pressure gauge assembly 70a which is not shown) through the tool electrical connector 68. Electrical connector 68 is, in 11 turn, is electrically connected preferably to the electronics present in each tool 12 section.
13 Fig. 5 illustrates conceptually a probe tool section 10a comprising a 14 port 94 that is in hydraulic communication with fluid in the borehole. This borehole fluid can be isolated by one or more packers such as a straddle packer 16 (not shown) controlled by the packer section 11 of the formation tester tool 10.
17 The port 94 is hydraulically coupled to the pressure gauge assemblies 70a and 18 70b (only assembly 70b is shown) again via the tool hydraulic connector 64 and 19 a fluid flow line 79b. Once again, elements are configured to minimize the length of the flow line 79b. Furthermore, electrical connection is again provided to the 21 pressure gauge assemblies 70a and 70b through the tool electrical connector 22 which, in turn, is electrically connected preferably to the electronics in each tool 23 section. It should be noted that. by using packers as an isolation means, 24 borehole fluid pressure measurements can be made in cased as well as uncased or "open" boreholes.
1 The gauges 82 and 84 are preferably calibrated by exposing the 2 pressure gauge assembly 70a, 70b or 70 to a known pressure at a known 3 ambient temperature as is normal in the industry.
4 The dual pressure gauges 82 and 84 provide redundant fluid pressure measurements at an area of common pressure in the borehole 6 environs. Any divergence in the two pressure measurements indicates that at 7 least one pressure gauge is malfunctioning. The response from the working 8 pressure gauge can be used to determine fluid pressure thereby avoiding 9 aborting the formation testing operation.
As discussed previously, the each pressure gauge assembly 70a, 11 70b or 70 is removably disposed in a recession or pocket 62 on the outer surface 12 of the tool section 10a (see Fig. 2a). This side loading feature allows one or 13 more assemblies to be rapidly changed. Due to the fragile nature of high 14 resolution pressure sensing gauges, the gauges can be transported separately in special handling containers and inserted into the formation tester tool 10 16 immediately prior to testing operations. This is possible as the pressure gauge 17 assemblies 70a, 70b or 70 are accessed from the outer surface of the tool 18 section 10a and can be easily removed and inserted. In addition, the same 19 pressure gauge assemblies 70a, 70b or 70 can be removably disposed sequentially in a plurality of tester tools 10 or tool sections 10a thereby 21 minimizing systematic gauge error in multiple runs or runs in multiple wells. .
22 This is especially important within a single well or for a field study of multiple 23 wells.
24 Pressure values are obtained for the numerous circumstances and conditions discussed above by combining responses of the pressure gauges 1 using a processor and preferably the processor disposed in the previously 2 discussed electronics section 22 (see Fig. 1).
Preferably two pressure gauge assemblies are used to provide 6 redundant pressure measurements at a given location of the borehole environs.
7 If the preferred two pressure gauge assemblies are used, each assembly 8 comprises a pressure sensing gauge. The pressure gauge assemblies are 9 disposed such that the pressure gauges are axially aligned with parallel major axes. If one pressure gauge assembly is used, two pressure gauges are axially 11 aligned within the assembly. Pressure gauge assemblies are removably 12 disposed within a receptacle or "pocket" in the outer surface of a formation tester 13 tool or formation tester tool section. When disposed or "side loaded" in the 14 pocket, the assembly's axially aligned gauges are positioned in a plane that is essentially normal to the radius of the formation tester tool. The axial alignment 16 or "side-by-side" geometry reduces and equalizes fluid flow line volumes 17 between the gauges as well as eliminating errors between the pressure gauges 18 due to hydrostatic head. Both the volumes are equal and the fluids are 19 identically the same for both gauges. This is important because the fluid properties such as compressibility and viscosity will be the same for these same 21 fluids of equal volume. This, in turn, is important during pressure transient 22 testing when fluid properties such as compressibility effects must be taken into 23 consideration. This is also important when doing pressure, volume, temperature 24 (PVT) testing. All of these features are not possible using axially spaced or "end-to-end" gauge geometry. The exposed geometry of the pressure gauge 1 assemblies allows quick stabilization to wellbore temperature. As well, the 2 exposed geometry in combination with the low mass of the gauges and the 3 cooperating heater assembly allow the pressure gauges to respond to rapid 4 wellbore temperatures changes that are encountered as the tool is moved up and down the well borehole. In addition, the heater assembly can assist raising 6 the pressure gauge temperature to the wellbore temperature rapidly.
7 Any divergence in pressure measurements between the dual 8 gauges indicates that at least one pressure gauge is malfunctioning. The 9 response of the working gauge can be used to determine fluid pressure thereby avoiding aborting the formation testing operation. The axial alignment or "side-11 by-side" gauge geometry reduces shut in fluid volumes when compared with an 12 "end-to-end" or axially spaced gauge geometry. The side loading feature of the 13 pressure gauge assembly allows the assembly to be changed with minimal 14 operation down time. Furthermore, the same pressure gauge assembly can be disposed sequentially in a plurality of tester tools thereby minimizing systematic 16 error in multiple run or multiple well testing operations.
17 While the foregoing disclosure is directed toward the preferred 18 embodiments of the invention, the scope of the invention is defined by the 19 claims, which follow.
Claims (17)
1. A pressure gauge comprising:
two axially aligned pressure sensing gauges wherein said pressure sensing gauges are of equal volume and are exposed to an area of common pressure;
a pressure gauge assembly comprising an assembly hydraulic connector that cooperates with a said pressure sensing gauge; wherein said pressure gauge assembly is removably disposed in a pocket in an outer surface of a formation tester tool section and hydraulically couples to a fluid flow line or to a hydraulic flow line within said formation tester tool section via said assembly hydraulic connector.
two axially aligned pressure sensing gauges wherein said pressure sensing gauges are of equal volume and are exposed to an area of common pressure;
a pressure gauge assembly comprising an assembly hydraulic connector that cooperates with a said pressure sensing gauge; wherein said pressure gauge assembly is removably disposed in a pocket in an outer surface of a formation tester tool section and hydraulically couples to a fluid flow line or to a hydraulic flow line within said formation tester tool section via said assembly hydraulic connector.
2. The gauge of claim 1 further comprising two said pressure gauge assemblies wherein one said pressure sensing gauge is disposed within each of said two pressure gauge assembly.
3. The gauge of claim 1 wherein said two pressure sensing gauges are disposed within said pressure gauge assembly.
4. The gauge of any one claims 1 to 3 further comprising a heater assembly cooperating with hydraulic fluid to control the temperature of said pressure sensing gauges.
5. The gauge of any one claims 1 to 4 wherein said two pressure sensing gauges are disposed in a plane essentially normal to the radius of said formation tool tester section.
6. A system for measuring pressure within a borehole, the system comprising:
(a) two pressure sensing gauges disposed within one or more pressure gauge assemblies, wherein said one or more pressure gauge assemblies each comprise (i) a assembly hydraulic connector cooperating with said one or more pressure sensing gauges disposed therein, wherein (ii) said one or more pressure gauge assemblies are configured to expose said two pressure sensing gauges therein to said pressure;
(b) a pocket containing a tool hydraulic connector; wherein (i) said pocket is disposed on an outer surface of a wall of a formation tester tool section, (ii) said one or more pressure gauge assemblies are removably disposed within said pocket such that said two pressure sensing gauges are axially aligned, and (iii) said two pressure sensing gauges are disposed in a plane essentially normal to the radius of said formation tool tester section; and (c) said one or more assembly hydraulic connectors and said tool hydraulic connector cooperate to hydraulically couple said one or more pressure gauge assemblies to a fluid flow line and to a hydraulic flow line within said formation tester tool section.
(a) two pressure sensing gauges disposed within one or more pressure gauge assemblies, wherein said one or more pressure gauge assemblies each comprise (i) a assembly hydraulic connector cooperating with said one or more pressure sensing gauges disposed therein, wherein (ii) said one or more pressure gauge assemblies are configured to expose said two pressure sensing gauges therein to said pressure;
(b) a pocket containing a tool hydraulic connector; wherein (i) said pocket is disposed on an outer surface of a wall of a formation tester tool section, (ii) said one or more pressure gauge assemblies are removably disposed within said pocket such that said two pressure sensing gauges are axially aligned, and (iii) said two pressure sensing gauges are disposed in a plane essentially normal to the radius of said formation tool tester section; and (c) said one or more assembly hydraulic connectors and said tool hydraulic connector cooperate to hydraulically couple said one or more pressure gauge assemblies to a fluid flow line and to a hydraulic flow line within said formation tester tool section.
7. The system of claim 6 further comprising a heater assembly thermally coupled to said pressure sensing gauges wherein:
(a) hydraulic fluid flows from said hydraulic flow line and through said cooperating tool hydraulic connector and said assembly hydraulic connectors and into said heater assembly; and (b) said heater assembly raises the temperature of said pressure sensing gauges.
(a) hydraulic fluid flows from said hydraulic flow line and through said cooperating tool hydraulic connector and said assembly hydraulic connectors and into said heater assembly; and (b) said heater assembly raises the temperature of said pressure sensing gauges.
8. The system of claim 6 or 7 further comprising a processor in which said pressure is determined from responses of said two pressure sensing gauges.
9. The system of any one of claims 6 to 8 wherein said formation tester tool section is conveyed within said borehole with a wireline
10. A method for obtaining a measure of pressure, the method comprising:
(a) simultaneously exposing two axially aligned pressure sensing gauges of equal volume to an area of common pressure;
(b) combining responses of said two pressure sensing gauges to obtain said measure of pressure;
(c) providing a pressure gauge assembly comprising an assembly hydraulic connector with which a said pressure sensing gauge cooperates;
(d) removably disposing said pressure gauge assembly in a pocket in an outer surface of a formation tester tool section; and (e) hydraulically coupling said pressure gauge assembly to a fluid flow line or to a hydraulic flow line within said formation tester tool section via said assembly hydraulic connector.
(a) simultaneously exposing two axially aligned pressure sensing gauges of equal volume to an area of common pressure;
(b) combining responses of said two pressure sensing gauges to obtain said measure of pressure;
(c) providing a pressure gauge assembly comprising an assembly hydraulic connector with which a said pressure sensing gauge cooperates;
(d) removably disposing said pressure gauge assembly in a pocket in an outer surface of a formation tester tool section; and (e) hydraulically coupling said pressure gauge assembly to a fluid flow line or to a hydraulic flow line within said formation tester tool section via said assembly hydraulic connector.
11. The method of claim 10 further comprising:
(a) providing two said pressure gauge assemblies; and (b) disposing one said pressure sensing gauge within each of said two pressure gauge assembly.
(a) providing two said pressure gauge assemblies; and (b) disposing one said pressure sensing gauge within each of said two pressure gauge assembly.
12. The method of claim 10 further comprising disposing said two pressure sensing gauges within said pressure gauge assembly.
13. The method of any one of claims 10 to 12 further comprising controlling the temperature of said pressure sensing gauges with a heater assembly cooperating with hydraulic fluid in thermal contact with said heater assembly.
14. The method of any one of claims 10 to 13 further comprising disposing said two pressure sensing gauges in a plane essentially normal to the radius of said formation tool tester section.
15. A method for measuring pressure within a borehole, the method comprising:
(a) providing two pressure gauge assemblies each comprising (i) a pressure sensing gauge of constant volume, and (ii) an assembly hydraulic connector cooperating with said pressure sensing gauge;
(b) configuring said pressure gauge assemblies to expose said two pressure sensing gauges therein to said pressure;
(c) providing a pocket containing a tool hydraulic connector wherein said pocket is disposed on an outer surface of a wall of a formation tester tool section;
(d) removably disposing said pressure gauge assemblies within said pocket wherein said pressure sensing gauges therein are (i) axially aligned, (ii) hydraulically coupled to said formation tester tool section via said assembly hydraulic connectors and said tool hydraulic connector; and (iii) disposed in a plane essentially normal to the radius of said formation tool tester section; and (e) determining said pressure by combining responses of said pressure sensing gauges.
(a) providing two pressure gauge assemblies each comprising (i) a pressure sensing gauge of constant volume, and (ii) an assembly hydraulic connector cooperating with said pressure sensing gauge;
(b) configuring said pressure gauge assemblies to expose said two pressure sensing gauges therein to said pressure;
(c) providing a pocket containing a tool hydraulic connector wherein said pocket is disposed on an outer surface of a wall of a formation tester tool section;
(d) removably disposing said pressure gauge assemblies within said pocket wherein said pressure sensing gauges therein are (i) axially aligned, (ii) hydraulically coupled to said formation tester tool section via said assembly hydraulic connectors and said tool hydraulic connector; and (iii) disposed in a plane essentially normal to the radius of said formation tool tester section; and (e) determining said pressure by combining responses of said pressure sensing gauges.
16. The method of claim 15 further comprising:
(a) thermally coupling a heater assembly to said pressure sensing gauges;
and (b) controlling the temperature of said pressure sensing gauges with said heater assembly.
(a) thermally coupling a heater assembly to said pressure sensing gauges;
and (b) controlling the temperature of said pressure sensing gauges with said heater assembly.
17. The method of claim 15 or 16 further comprising conveying said formation tester tool section within said borehole with a wireline.
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|---|---|---|---|
| US11/855,577 | 2007-09-14 | ||
| US11/855,577 US7805999B2 (en) | 2007-09-14 | 2007-09-14 | Apparatus and methods for measuring pressure using a formation tester |
Publications (2)
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| CA2637561A1 CA2637561A1 (en) | 2009-03-14 |
| CA2637561C true CA2637561C (en) | 2012-04-24 |
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| AU (1) | AU2008203100B8 (en) |
| BR (1) | BRPI0804130A2 (en) |
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| EP2844835A4 (en) * | 2012-05-04 | 2016-11-16 | Halliburton Energy Services Inc | Method and apparatus for use of electronic pressure gauge in extreme high temperature environment |
| US9704620B2 (en) * | 2012-06-15 | 2017-07-11 | João Martins Neto | Cable gland with pressure indicator |
| US9598952B2 (en) | 2012-09-26 | 2017-03-21 | Halliburton Energy Services, Inc. | Snorkel tube with debris barrier for electronic gauges placed on sand screens |
| EP2900914B1 (en) * | 2012-09-26 | 2019-05-15 | Halliburton Energy Services, Inc. | Welbore sensing system and method of sensing in a wellbore |
| AU2012391060B2 (en) | 2012-09-26 | 2017-02-02 | Halliburton Energy Services, Inc. | Method of placing distributed pressure gauges across screens |
| US10248141B2 (en) * | 2016-05-13 | 2019-04-02 | Cameron International Corporation | Non-invasive pressure measurement system |
| CN106996841B (en) * | 2017-05-27 | 2022-11-22 | 吉林大学 | Drilling type optical fiber three-dimensional ground stress observation device with self-consistent function |
| CN109931708B (en) * | 2019-02-27 | 2020-06-02 | 珠海格力电器股份有限公司 | Water supply system, heating control method thereof, and computer-readable storage medium |
| CN112483073B (en) * | 2020-12-15 | 2023-07-04 | 贵州航天凯山石油仪器有限公司 | Multifunctional pressure gauge mounting device |
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| US1162A (en) * | 1839-05-30 | Mode of regulating- the jaws of leather-crimping machines | ||
| US2223786A (en) * | 1937-01-21 | 1940-12-03 | Shell Dev | Borehole pressure gauge |
| SU953195A1 (en) | 1980-12-15 | 1982-08-23 | Азербайджанское Отделение Всесоюзного Научно-Исследовательского Института Геофизических Методов Разведки | Apparatus for measuring pressure and temperature in a well |
| US4596139A (en) * | 1985-01-28 | 1986-06-24 | Mobil Oil Corporation | Depth referencing system for a borehole gravimetry system |
| CA2034444C (en) | 1991-01-17 | 1995-10-10 | Gregg Peterson | Method and apparatus for the determination of formation fluid flow rates and reservoir deliverability |
| US5457988A (en) * | 1993-10-28 | 1995-10-17 | Panex Corporation | Side pocket mandrel pressure measuring system |
| US5796007A (en) * | 1996-09-23 | 1998-08-18 | Data Instruments, Inc. | Differential pressure transducer |
| US6301959B1 (en) | 1999-01-26 | 2001-10-16 | Halliburton Energy Services, Inc. | Focused formation fluid sampling probe |
| US6246048B1 (en) * | 1999-05-18 | 2001-06-12 | Schlumberger Technology Corporation | Methods and apparatus for mechanically enhancing the sensitivity of longitudinally loaded fiber optic sensors |
| US6663352B2 (en) * | 2001-07-25 | 2003-12-16 | Itt Manufacturing Enterprises, Inc. | Method and apparatus for dynamically determining vapor pressure in pumping systems |
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| AU2008203100B2 (en) | 2010-07-29 |
| GB2452804A (en) | 2009-03-18 |
| US7805999B2 (en) | 2010-10-05 |
| NO20083827L (en) | 2009-03-16 |
| BRPI0804130A2 (en) | 2009-06-16 |
| GB2452804B (en) | 2010-04-07 |
| GB2464633B (en) | 2010-07-28 |
| AU2008203100B8 (en) | 2010-12-16 |
| GB2464633A (en) | 2010-04-28 |
| GB201000633D0 (en) | 2010-03-03 |
| GB0812710D0 (en) | 2008-08-20 |
| CA2637561A1 (en) | 2009-03-14 |
| AU2008203100A8 (en) | 2010-12-16 |
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Effective date: 20210715 |